System and method for enhanced removal of co2 from a mixed gas stream

ABSTRACT

A solvent based flue gas processing system for removing CO 2  from a flue gas stream is provided in which a catalyst coated on a support structure is provided. The catalyst selected is capable of retaining CO 2 , at least for a period of time, thereby increasing the residence time of CO 2  and solvent.

CROSS REFERENCE TO RELATED APPLICATION(S)

This application claims priority to co-pending U.S. provisional application entitled, “System and Method For Enhanced Removal of CO₂ From a Mixed Gas Stream,” having U.S. Ser. No. 61/038,494, filed Mar. 21, 2008, the disclosure of which is entirely incorporated herein by reference.

FIELD OF THE INVENTION

The proposed invention relates to a system and method for removing carbon dioxide (CO₂) from a process gas stream containing carbon dioxide and sulphur dioxide. More particularly, the proposed invention is directed to a solvent based flue gas processing system for removing CO₂ from a flue gas stream in which a catalyst is provided to increase the efficiency of the solvent in capturing CO₂ from the flue gas stream or in regenerating the solvent.

BACKGROUND

In the combustion of a fuel, such as coal, oil, peat, waste, etc., in a combustion plant, such as those associated with boiler systems for providing steam to a power plant, a hot process gas (or flue gas) is generated. Such a flue gas will often contain, among other things, carbon dioxide (CO₂) The negative environmental effects of releasing carbon dioxide to the atmosphere have been widely recognised, and have resulted in the development of processes adapted for removing carbon dioxide from the hot process gas generated in the combustion of the above mentioned fuels. One such system and process has previously been disclosed and is directed to a single-stage Chilled Ammonia based system and method for removal of carbon dioxide (CO₂) from a post-combustion flue gas stream.

Known solvent based CO₂ capture systems, such as ammonia based systems and processes (CAP) provide a relatively low cost means for capturing/removing CO₂ from a gas stream, such as, for example, a post combustion flue gas stream. An example of such a system and process has previously been disclosed in pending patent application PCT/US2005/012794 (international Publication Number: WO 2006/022885/Inventor: Eli Gal)), filed on 12 Apr. 2005 and titled Ultra Cleaning of Combustion Gas Including the Removal of CO₂. In this process the absorption of CO₂ from a flue gas stream is achieved by contacting a chilled ammonia ionic ammonia solution (or slurry) with a flue gas stream that contains CO₂.

FIG. 1A is a diagram generally depicting a flue gas processing system 15 for use in removing various pollutants from a flue gas stream FG emitted by the combustion chamber of a boiler system 26 used in a steam generator system of, for example, a power generation plant. This system includes a CO₂ removal system 70 that is configured to remove CO₂ from the flue gas stream FG before emitting the cleaned flue gas stream to an exhaust stack 90 (or alternatively additional processing). It is also configured to output CO₂ removed from the flue gas stream FG. Details of CO₂ removal system 70 are generally depicted in FIG. 1B.

With reference to FIG. 1B, CO₂ removal System 70 includes a capture system 72 for capturing/removing CO₂ from a flue gas stream FG and a regeneration system 74 for regenerating ionic ammonia solution used to remove CO₂ from the flue gas stream FG. Details of capture system 72 are generally depicted in FIG. 1C.

With reference to FIG. 1C and FIG. 1D, a capture system 72 of a CO₂ capture system 70 (FIG. 1A) is generally depicted. In this system, the capture system 72 is a solvent based CO₂ capture system. More particularly, in this example, the solvent used is chilled ammonia. In a chilled ammonia (CAP) based system/method for CO₂ removal, an absorber vessel is provided in which an absorbent ionic ammonia solution (ionic ammonia solution) is contacted with a flue gas stream (FG) containing CO₂. The ionic ammonia solution is typically aqueous and may be composed of, for example, water and ammonium ions, bicarbonate ions, carbonate ions, and/or carbamate ions. An example of a known CAP CO₂ removal system is generally depicted in the diagrams of FIG. 1C and FIG. 1D.

With reference to FIG. 1C, an absorber vessel 170 is configured to receive a flue gas stream (FG) originating from, for example, the combustion chamber of a fossil fuel fired boiler 26 (see FIG. 1A). It is also configured to receive a lean ionic ammonia solution supply from regeneration system 74 (see FIG. 1B). The lean ionic ammonia solution is introduced into the vessel 170 via a liquid distribution system 122 while the flue gas stream FG is also received by the absorber vessel 170 via flue gas inlet 76.

The ionic ammonia solution is put into contact with the flue gas stream via a gas-liquid contacting device (hereinafter, mass transfer device, MTD) 111 used for contacting the flue gas stream with solvent and located in the absorber vessel 170 and within the path that the flue gas stream travels from its entrance via inlet 76 to the vessel exit 77. The gas-liquid contacting device 111 may be, for example, one or more commonly known structured or random packing materials, or a combination thereof.

Once contacted with the flue gas stream, the ionic ammonia solution acts to absorb CO₂ from the flue gas stream, thus making the ionic ammonia solution “rich” with CO₂ (rich solution). The rich ionic ammonia solution continues to flow downward through the mass transfer device and is then collected in the bottom 78 of the absorber vessel 170. The rich ionic ammonia solution is then regenerated via regenerator system 74 (see FIG. 1B) to release the CO₂ absorbed by the ionic ammonia solution from the flue gas stream. The CO₂ released from the ionic ammonia solution may then be output to storage or other predetermined uses/purposes. Once the CO₂ is released from the ionic ammonia solution, the ionic ammonia solution is said to be “lean”. The lean ionic ammonia solution is then again ready to absorb CO₂ from a flue gas stream and may be directed back to the liquid distribution system 121 whereby it is again introduced into the absorber vessel 170. Details of regenerating system 74 are shown in FIG. 1E. System 74 includes a regenerator vessel 195. Regenerator vessel 195 is configured to receive a rich solution feed from the capture system 72 and to return a lean solution feed to the capture system 72 once CO₂ has been separated from the rich solution.

During the regeneration process, the rich ionic ammonia solution is heated so that CO₂ contained in the solution separates from the chilled ammonia solution. Once separated from the CO₂, ammonia (ammonia slip) is returned to the capture system for use in capturing further CO₂ from a gas stream.

These currently known solvent based CO₂ capture technologies typically consume approximately 20-30% of the power generated by the power generation system in order for the CO₂ capture process to work effectively. In addition, these technologies often require a large portion of thermal energy generated by boiler/re-boiler functions (reboiler duty) in order to regenerate amine solution for 10 re-use in capturing CO₂ from a flue gas stream. In short, while there are known technologies for capturing CO₂ from a flue gas stream, they require immense amounts of energy in order to function well. Further, in order to maximize/optimize the amount of time that flue gas is in contact with amine, the physical size of the absorber and/or re-generator tanks in a typical system must be very large. The cost to design and implement these towers of such large scale is very high. Additionally, the physical space that is required on-site to accommodate these vessels is significant. Where on-site space is limited, additional steps must be taken to implement the vessels/system in the limited space, if possible.

SUMMARY OF THE INVENTION

Embodiments of the present invention provide for flue gas processing system for use with a fossil fuel fired boiler. Briefly described, in architecture, one embodiment of the system, among others, can be implemented as a flue gas processing system that includes an absorber tower configured to receive a mixed gas stream containing carbon dioxide and to contact it with a solvent; and the absorber tower comprises packing materials that are coated with a catalyst.

Embodiments of the present invention can also be viewed as providing methods for processing a mixed gas stream wherein the method includes the steps of: receiving a flue gas stream from the combustion chamber of a boiler; contacting the flue gas stream with a solvent and contacting the solvent with a catalyst.

Other systems, methods, features, and advantages of the present invention will be or become apparent to one with skill in the art upon examination of the following drawings and detailed description. It is intended that all such additional systems, methods, features, and advantages be included within this description, be within the scope of the present invention, and be protected by the accompanying claims.

BRIEF DESCRIPTION OF THE DRAWINGS

Many aspects of the invention can be better understood with reference to the following drawings. The components in the drawings are not necessarily to scale, emphasis instead being placed upon clearly illustrating the principles of the present invention. Moreover, in the drawings, like reference numerals designate corresponding parts throughout the several views. The invention will now be described in more detail with reference to the appended drawings in which:

FIG. 1A-FIG. 1C are diagram generally depicting a typical flue gas processing system 15 with provisions for CO₂ removal.

FIG. 2A-FIG. 2D are diagrams generally illustrating an example of packing materials 315 on which a catalyst capable of holding CO₂ has been immobilized on the wall/surfaces of the packing materials 315.

FIG. 3 is a diagram generally depicting relevant portions of an amine or ammonia based CO₂ capture system 70 in which absorber 110 and regenerator 330 are provided with packing materials 315 and 335, respectively that have been coated with a catalyst capable of holding CO₂.

DISCUSSION

The proposed invention is directed to increasing CO₂ removal efficiency in a solvent based (amine/ammonia) CO₂ removal system/process. In one embodiment, generally depicted in FIG. 2A-FIG. 3, a mass transfer device MTD 315 (or packing materials) composed of, for example, one or more support structures 320 is provided and disposed within the interior of an absorber vessel 110 (FIG. 3). The support structure(s) 320 is coated with a catalyst 425.

FIG. 2A-FIG. 2D are diagrams generally depicting packing materials 315 that have been coated with a solid material capable of holding CO₂ 425. FIG. 2B and 2C shows that the packing materials 315 may be composed of, for example, a series of corrugated support structures 320 arranged in close proximity to each other so as to form a series of channels 334 through which flue gas entering the absorber vessel 110 flow. The catalyst 425 is coated on one or more surfaces of each corrugated support structures 320.

The catalyst coated on the support structure(s) 320 will preferably be a heterogeneous catalyst. Further the catalyst 425 will preferably have a moderate basicity/interaction with CO₂ and high specific surface area, for example, 100-1000 m²/g. Preferably the catalyst 425 will be a commercially available catalyst having a high BET (Brunauer, Emmett and Teller) surface area and porosity (polymer, metal oxides, SiO₂, molecular sieves, etc.), which should be able to store or retain CO₂ with moderate interaction (basicity) with the catalyst. Surface basicity may be tuned by, for example, surface modification using alkali/alkali earth metal or transition metal oxide in order to enhance CO₂ adsorption capacity. The catalyst 425 can be immobilized onto the support structures(s) 320 by using, for example, known wash-coating techniques.

In operation, the flue gas stream is contacted with the packing materials 315 and thus, the support structure 320 that is coated (layered) with the catalyst 425 capable of holding/retaining CO₂ from the flue gas stream for at least a period of time. By retaining CO₂ on the catalyst disposed on the support structure 320, the CO₂ is exposed to solvent flowing through the packing materials 115, counter current to the flue gas stream, for a longer period of time, thus increasing the likelihood that the CO₂ will be captured by the solvent.

In this way, it is possible to indirectly increase the residence time of the CO₂ contained in a flue gas stream with the solvent (amine/ammonia) in absorber tower 110 and thus, increase the amount of CO₂ that will be adsorbed onto the surface of the solid materials. In order to do this, it is proposed in one embodiment of the proposed invention, that a solid material capable of holding (adsorbing) CO₂ for a period of time be immobilized (coated) on one or more surfaces of the packing materials 315 used in the absorber tower 110 (FIG. 3)) of a solvent based CO₂ capture system.

FIG. 3 is a diagram generally depicting relevant portions of an solvent based (example: amine or ammonia) based CO₂ capture system 300 for use in processing a flue gas stream from, for example, a fossil fuel fired boiler of a power generation plant. The system 300 includes an absorber tower 110 that includes packing materials 315 that are coated with a catalyst 425 on one or more surfaces. A regeneration tower 330 is provided and includes packing materials 339 that are coated with a catalyst 425 on one or more surfaces.

While the invention has been described with reference to a number of preferred embodiments, it will be understood by those skilled in the art that various changes may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In addition, many modifications may be made to adapt a particular situation or material to the teachings of the invention without departing from the essential scope thereof. Therefore, it is intended that the invention not be limited to the particular embodiments disclosed as the best mode contemplated for carrying out this invention, but that the invention will include all embodiments falling within the scope of the appended claims. Moreover, the use of the terms first, second, etc. do not denote any order or importance, but rather the terms first, second, etc. are used to distinguish one element from another. 

1. A flue gas processing system comprising: absorber tower configured to receive a mixed gas stream containing carbon dioxide and to contact it with a solvent; and the absorber tower comprises packing materials that are coated with a catalyst.
 2. The system of claim 1 wherein the catalyst is a heterogeneous catalyst.
 3. The system of claim 1 wherein said flue gas system is an amine based flue gas processing system.
 4. The system of claim 3 wherein the catalyst provided to promote the capture of carbon dioxide within the flue gas stream with amine.
 5. The system of claim 1 wherein said mixed gas system is ammonia based mixed gas processing system.
 6. A mixed gas processing system comprising: regeneration tower configured to receive a carbon dioxide rich amine stream; and the regeneration tower comprises packing materials that are coated/immobilized with a catalyst.
 7. The system of claim 6 wherein the catalyst is a heterogeneous catalyst.
 8. A mixed gas processing system comprising: regeneration tower configured to receive a carbon dioxide rich ammonia stream; and the regeneration tower comprises packing materials that are coated with a catalyst.
 9. The system of claim 8 wherein the catalyst is a heterogeneous catalyst.
 10. A mixed gas processing system comprising an absorber tower configured to receive a flue gas stream and an amine feed supply that includes a catalyst.
 11. The system of claim 10 wherein the absorber tower is configured to cause the flue gas stream to contact amine/catalyst from the amine feed supply.
 12. A mixed gas processing system comprising: absorber tower configured to receive a flue gas stream; and the absorber tower comprises packing materials that are coated/immobilized with a catalyst which can be used to activate CO₂ adsorbed onto its surfaces and catalyse carbonation/bi-carbonation and carbomation of amine with CO₂.
 13. A mixed gas processing system comprising: regeneration tower configured to receive a carbon dioxide rich amine stream; and the regeneration tower comprises packing materials that are coated/immobilized with a catalyst which can be used to catalyse the decomposition of products formed from the carbonation/bi-carbonation and carbomation of amine with CO₂.
 14. A mixed gas processing system comprising: regeneration tower configured to receive a carbon dioxide rich ammonia stream; and the regeneration tower comprises packing materials that are coated/immobilized with a catalyst which can be used to catalyse the decomposition of products formed from the reaction/interaction of ammonia with CO₂.
 15. A mixed gas processing system comprising an absorber tower configured to receive a flue gas stream and an amine feed supply that includes a catalyst which can be used to catalyse CO₂ capture using amine/ammonia at low temperature and also the decomposition of products formed from the reaction/interaction of ammonia with CO₂ at high temperature. 